Systems and methods of converting renewable feedstocks into intermediate hydrocarbon blend stocks and transportation fuels

ABSTRACT

Systems and methods to provide renewable transportation fuels for internal combustion engines by converting renewable feedstocks into two or more intermediate hydrocarbon blend stocks and blending at least two of the two or more intermediate hydrocarbon blend stocks to produce the renewable transportation fuel. Methods and/or processes may include selecting sugar from a sugar source and introducing the sugar into one or more reactors. The sugar may be converted into an intermediate renewable hydrocarbon blend stock and sent to a separation unit to separate out an intermediate renewable gasoline unit. The process may include selecting and converting a lipid from a lipid source into a renewable diesel product. The renewable diesel product may be sent to a second separation unit to separate out renewable diesel and a low-grade naphtha. The low-grade naphtha and intermediate renewable gasoline may be blended to define a finished renewable gasoline.

PRIORITY CLAIM

This is a continuation of U.S. Non-Provisional application Ser. No.18/112,565, filed Feb. 22, 2023, titled “SYSTEMS AND METHODS OFCONVERTING RENEWABLE FEEDSTOCKS INTO INTERMEDIATE HYDROCARBON BLENDSTOCKS AND TRANSPORTATION FUELS,” which is a continuation of U.S.Non-Provisional application Ser. No. 17/848,443, filed Jun. 24, 2022,titled “SYSTEMS AND METHODS OF CONVERTING RENEWABLE FEEDSTOCKS INTOINTERMEDIATE HYDROCARBON BLEND STOCKS AND TRANSPORTATION FUELS,” nowU.S. Pat. No. 11,613,715, issued Mar. 28, 2023, which claims priority toand the benefit of U.S. Provisional Application No. 63/262,426, filedOct. 12, 2021, titled “SYSTEMS AND METHODS OF CONVERTING RENEWABLEFEEDSTOCKS INTO INTERMEDIATE HYDROCARBON BLEND STOCKS AND TRANSPORTATIONFUELS,” the disclosures of which are incorporated herein.

FIELD OF THE DISCLOSURE

Embodiments herein generally relate to renewable transportation fuels.More specifically, one or more embodiments relate to convertingrenewable feedstocks into two or more intermediate hydrocarbon blendstocks and blending at least two of the two or more intermediatehydrocarbon blend stocks to produce the renewable transportation fuel.

BACKGROUND

Technologies have been developed to produce refined products for use intransportation fuels using renewable feedstock or materials. Theseproducts may be transported to a traditional refinery or terminal to beblended into fossil-based fuels. The renewable diesel facilities,ethanol plants and/or other renewable transportation fuel units aretypically located at separate sites or locations apart from each otherand traditional refineries/terminals. As such, products produced by eachfacility must be transported for blending or further processing. Forexample, the diesel product formed by some renewable diesel facilitiescontain ringed components, have low cetane (e.g., a cetane numberbetween about −30 to 10), and is dark in color. Such a diesel productcannot be blended into California Air Resources Board (CARE) diesel orultra-low sulfur diesel (ULSD) diesel at appreciable volumes withoutfurther processing.

SUMMARY

Accordingly, Applicants have recognized a need for systems and methodsto provide renewable transportation fuels for internal combustionengines by converting renewable feedstocks into two or more intermediatehydrocarbon blend stocks and blending at least two of the two or moreintermediate hydrocarbon blend stocks to produce the renewabletransportation fuel. The renewable feedstocks may be produced at arefinery or facility via co-located, on-site units. The integration ofthe co-located, on-site units enables a refinery or facility to fullyutilize renewable feedstocks. The refinery or facility leveragesco-location efficiencies, economies of scale associated with supportinfrastructure, and operating expense savings. Such systems and methodsallow for the further processing of renewable feedstocks without theneed for carbon-intensive and expensive transportation. The presentdisclosure is directed to embodiments of such systems and methods.

The present disclosure is generally directed to systems and methods forproviding renewable transportation fuels for internal combustion enginesby converting renewable feedstocks into two or more intermediatehydrocarbon blend stocks and blending at least two of the two or moreintermediate hydrocarbon blend stocks to produce the renewabletransportation fuel. The renewable feedstocks may be produced at arefinery or facility via co-located, on-site units. The conversion andseparation of sugar from a source and lipids from a source may producetwo or more renewable feedstocks. At least two of the two or morerenewable feedstocks may be blended to produce a renewabletransportation fuel. The renewable transportation fuel may include arenewable gasoline, renewable aviation fuel, renewable or sustainablemarine fuel, or renewable liquefied petroleum gas (LPG). The integrationof the co-located, on-site units enables the refinery or facility toutilize and produce fully renewable feedstocks by leveraging co-locationefficiencies and existing support infrastructure.

Accordingly, an embodiment of the disclosure is directed to a process toprovide renewable transportation fuels for internal combustion enginesby converting renewable feedstocks into two or more intermediatehydrocarbon blend stocks and blending at least two of the two or moreintermediate hydrocarbon blend stocks to produce the renewabletransportation fuel. The process may include introducing sugar into oneor more reactors. The process may include converting the sugar into anintermediate renewable hydrocarbon blend stock through hydrogenation ofthe sugar, hydrodeoxygenation of the hydrogenated sugar, and acidcondensation of the hydrodeoxygenated, and hydrogenated sugar within theone or more reactors. The process may include passing the intermediaterenewable hydrocarbon blend stock through a first separation unit toseparate out at least an intermediate renewable gasoline blend stock.The process may include introducing one or more lipids into a renewablediesel unit. The process may include operating the renewable diesel unitto yield a renewable diesel product from the one or more lipids. Therenewable diesel product may include at least a low-grade naphtha and arenewable diesel via a hydrotreated vegetable oil or hydroprocessedesters and fatty acids process. The process may include passing therenewable diesel product through a second separation unit to separateout at least a renewable diesel and a low-grade naphtha. The low-gradenaphtha may have a benzene content less than about 0.5 volume percentand a research octane number of less than about 60. The process mayinclude blending the low-grade naphtha and the intermediate renewablegasoline blend stock to define a finished renewable gasoline; andoutputting the finished renewable gasoline for use in internalcombustion engines.

In another embodiment, the process may further include introducing acarbohydrate feedstock to an ethanol plant. The process may includeoperating an ethanol fermentation and distillation process in theethanol plant to convert the carbohydrate feedstock into at least anethanol product. The process may include separating an ethanol blendstock from the ethanol product in an ethanol separator. The process mayinclude blending the ethanol blend stock with the low-grade naphtha andthe intermediate renewable gasoline blend stock to define the finishedrenewable gasoline.

In another embodiment, the process may include, prior to introducing thesugar to one or more reactors, selecting the sugar from a sugar source.The sugar source may be a wet or dry mill. The process may furtherinclude, prior to introducing the one or more lipids into the renewablediesel unit, selecting the one or more lipids from a lipid source. Theone or more lipids may comprise one or more of vegetable oils, animalfats, used cooking oil, other lipids, or some combination thereof.

In another embodiment, the process may further include introducingrenewable natural gas as a reformer unit feedstock to a reformer unit.The process may include producing at least hydrogen gas throughconversion of the renewable natural gas in the reformer unit. Theprocess may include introducing at least a portion of the hydrogen gasinto at least one of the one or more reactors to hydrogenate the sugaror dehydrodeoxygenate the hydrogenated sugar.

In another embodiment, the process may further include introducingrenewable natural gas as a reformer unit feedstock to a reformer unit.The process may include producing at least hydrogen gas by conversion ofthe renewable natural gas in the reformer unit. The process may includeintroducing at least a portion of the hydrogen gas into the renewablediesel unit to produce the renewable diesel and the low-grade naphtha.

In another embodiment, the intermediate renewable hydrocarbon blendstock further includes a first sustainable aviation fuel blend stockthat contains synthesized kerosene (SK) or synthesized aromatic kerosene(SAK) and the renewable diesel product further includes a secondsustainable aviation fuel blend stock that contains hydroprocessedesters and fatty acids-synthetic paraffinic kerosene (HEFA-SPK). In suchembodiments, the process may further include separating the firstsustainable aviation fuel blend stock from the intermediate renewablehydrocarbon blend stock in the first separation unit. The process mayinclude separating the second sustainable aviation fuel blend stock fromthe renewable diesel unit in the second separation unit. The process mayinclude blending the first sustainable aviation fuel blend stock and thesecond sustainable aviation fuel blend stock into a renewablesustainable aviation fuel.

In another embodiment, the intermediate renewable hydrocarbon blendstock may further include a precursor marine fuel blend stock. In suchembodiments, the process may include separating the precursor marinefuel blend stock from the intermediate renewable hydrocarbon blend stockin the first separation unit. The process may include blending an amountof the renewable diesel with the precursor marine fuel blend stock todefine a renewable marine fuel.

In another embodiment, the finished renewable gasoline may be output asa non-petroleum based fuel. The finished renewable gasoline may besubstantially devoid of any fossil fuel-derived components.

Another embodiment of the disclosure is directed to a process to providerenewable transportation fuels for internal combustion engines byconverting renewable feedstocks into two or more intermediatehydrocarbon blend stocks and blending at least two of the two or moreintermediate hydrocarbon blend stocks to produce the renewabletransportation fuel. The process may include introducing a sugar intoone or more reactors. The process may include converting the sugar intoan intermediate renewable hydrocarbon blend stock through hydrogenationof the sugar, hydrodeoxygenation of the hydrogenated sugar, and acidcondensation of the hydrodeoxygenated, hydrogenated sugar within the oneor more reactors. The process may include passing the intermediaterenewable hydrocarbon blend stock through a first separation unit toseparate out at least a first sustainable aviation fuel blend stock thatcontains synthesized kerosene (SK) or synthesized aromatic kerosene(SAK). The process may include introducing one or more lipids into arenewable diesel unit. The process may include operating the renewablediesel unit to yield a renewable diesel product from the one or morelipids. The process may include passing the renewable diesel productthrough a second separation unit to separate out at least a secondsustainable aviation fuel blend stock that has at least one ofhydroprocessed esters and fatty acids-synthetic paraffinic kerosene(HEFA-SPK). The process may include receiving the first sustainableaviation fuel blend stock from the first separation unit. The processmay include receiving the second sustainable aviation fuel blend stockfrom the second separation unit. The process may include blending atleast the first sustainable aviation fuel blend stock and the secondsustainable aviation fuel blend stock to define a sustainable aviationfuel. The process may include outputting the sustainable aviation fuelfor use in internal combustion engines.

Another embodiment of the disclosure is directed to a process to providerenewable transportation fuels for internal combustion engines byconverting renewable feedstocks into two or more intermediatehydrocarbon blend stocks and blending at least two of the two or moreintermediate hydrocarbon blend stocks to produce the renewabletransportation fuel. The process may include selecting sugar from asugar source. The process may include introducing the sugar into one ormore reactors. The process may include converting the sugar into anintermediate renewable hydrocarbon blend stock through hydrogenation ofthe sugar, hydrodeoxygenation of the hydrogenated sugar, and acidcondensation of the hydrodeoxygenated, hydrogenated sugar within the oneor more reactors. The process may include passing the intermediaterenewable hydrocarbon blend stock through a first separation unit toseparate out at least a sustainable marine fuel blend stock. The processmay include selecting one or more lipids from a lipid source. Theprocess may include introducing the one or more lipids into a renewablediesel unit. The process may include operating the renewable diesel unitto yield a renewable diesel product from the one or more lipids. Theprocess may include passing the renewable diesel product through asecond separation unit to separate out at least a renewable diesel. Theprocess may include receiving the sustainable marine fuel blend stockfrom the first separation unit. The process may include receiving therenewable diesel from the second separation unit. The process mayinclude blending at least the sustainable marine fuel blend stock andthe renewable diesel to define a sustainable marine fuel. The processmay include outputting the sustainable marine fuel for use in internalcombustion engines.

Another embodiment of the disclosure is directed to a process to providerenewable transportation fuels for internal combustion engines byconverting renewable feedstocks into two or more intermediatehydrocarbon blend stocks and blending at least two of the two or moreintermediate hydrocarbon blend stocks to produce the renewabletransportation fuel. The process may include selecting sugar from asugar source. The process may include introducing the sugar into one ormore reactors. The process may include converting the sugar into anintermediate renewable hydrocarbon blend stock through hydrogenation ofthe sugar, hydrodeoxygenation of the hydrogenated sugar, and acidcondensation of the hydrodeoxygenated, hydrogenated sugar within the oneor more reactors. The process may include passing the intermediaterenewable hydrocarbon blend stock through a first separation unit toseparate out at least a first intermediate light ends stream containingfirst intermediate light ends. The process may include selecting one ormore lipids from a lipid source. The process may include introducing theone or more lipids into a renewable diesel unit. The process may includeoperating the renewable diesel unit to yield a renewable diesel productfrom the one or more lipids. The process may include passing therenewable diesel product through a second separation unit to separateout at least a second intermediate light ends steam containing secondintermediate light ends. The process may include introducing the firstintermediate light ends from the first intermediate lights ends streamand the second intermediate light ends from the second intermediatelight ends stream into a third separation unit. The process may includeoperating the third separation unit to separate the first and secondintermediate lights ends into at least a renewable LPG product and afuel gas. The process may include outputting the renewable LPG productfor use in internal combustion engines.

In another embodiment, the process may include passing the fuel gas to asteam reformer. The process may include combusting at least a portion ofthe fuel gas to produce hydrogen gas in the steam reformer.

Accordingly, another embodiment of the disclosure is directed to asystem to provide renewable transportation fuels for internal combustionengines that converts renewable feedstocks into two or more intermediatehydrocarbon blend stocks and blends at least two of the two or moreintermediate hydrocarbon blend stocks to produce the renewabletransportation fuel. The system may include a source of sugar. Thesystem may include at least one reactor with an inlet to receive thesugar from the source of sugar and an outlet. The at least one reactormay be configured to hydrogenate the sugar, hydrodeoxygenate thehydrogenated sugar, and facilitate acid condensation of thehydrodeoxygenated, hydrogenated sugar to produce an intermediaterenewable hydrocarbon blend stock. The system may include a firstseparation unit connected to and in fluid communication with the outletof the at least one reactor. The first separation unit may be operableto separate the intermediate renewable hydrocarbon blend stock into atleast an intermediate renewable gasoline blend stock. The system mayinclude a source of lipids. The system may include a renewable dieselunit with an inlet to receive the lipid from the source of lipids and anoutlet. The renewable diesel unit may be configured to yield a renewablediesel product from the one or more lipids. The system may include asecond separation unit connected to and in fluid communication with theoutlet of the renewable diesel unit. The second separation unit may beoperable to separate the renewable diesel product into at least arenewable diesel blend stock and a low-grade naphtha. The low-gradenaphtha may have a benzene content less than about 0.5 volume percentand a research octane number of less than about 60.

In another embodiment, the system may include a source of carbohydratefeedstock. The system may include an ethanol production plant with aninlet that receives the carbohydrate feedstock from the source ofcarbohydrate feedstock. The ethanol production plant may be operable toconvert the carbohydrate feedstock into an ethanol blend stock thatleaves the ethanol production plant through an outlet thereof. Thesystem may include a flow line between the outlet of the ethanolproduction plant and the blending unit to pass the ethanol blend stockto the blending unit for blending with the intermediate renewablegasoline blend stock and the low-grade naphtha.

Accordingly, anther embodiment of the disclosure is directed to a methodfor producing renewable transportation fuels, within a refinery, forinternal combustion engines that converts renewable feedstocks into twoor more intermediate hydrocarbon blend stocks and blends at least two ofthe two or more intermediate hydrocarbon blend stocks to produce therenewable transportation fuel. The method may include introducing sugarto one or more reactors co-located with a refinery. The method mayinclude converting the sugar into an intermediate renewable hydrocarbonblend stock through within the one or more reactors. The method mayinclude separating the intermediate renewable hydrocarbon blend stockinto a first intermediate renewable blend stock within a firstseparation unit co-located with the refinery. The method may includeintroducing one or more lipids into a renewable diesel unit co-locatedwith the refinery. The method may include operating the renewable dieselunit to yield a renewable diesel product from the one or more lipids.The method may include separating the renewable diesel product into asecond intermediate renewable blend stock within a second separationunit co-located with the refinery. The method may include blending thefirst intermediate blend stock and the second intermediate blend stockwithin a blend unit co-located with the refinery. A blend of the firstintermediate blend stock and the second intermediate blend stock todefine a finished renewable transportation fuel.

Still other aspects and advantages of these and other embodiments arediscussed in detail herein. Moreover, it is to be understood that boththe foregoing information and the following detailed description providemerely illustrative examples of various aspects and embodiments and areintended to provide an overview or framework for understanding thenature and character of the claimed aspects and embodiments.Accordingly, the advantages and features of the present disclosure willbecome more apparent through reference to the following description andthe accompanying drawings. Furthermore, it is to be understood that thefeatures of the various embodiments described herein are not mutuallyexclusive and may exist in various combinations and permutations.

BRIEF DESCRIPTION OF DRAWINGS

These and other features, aspects, and advantages of the disclosure willbecome better understood with regard to the following descriptions,claims, and accompanying drawings. It is to be noted, however, that thedrawings illustrate only several embodiments of the disclosure and,therefore, are not to be considered limiting of the scope of thedisclosure.

FIG. 1 is a schematic diagram of a co-located refinery, according to oneor more embodiments disclosed herein;

FIGS. 2A through 2F are flow diagrams for producing renewabletransportation fuel at a co-located refinery, according to one or moreembodiments disclosed herein; and

FIGS. 3A through 3B are schematic diagrams of one or more controllers tocoordinate the production of the transportation fuel, according to oneor more embodiments disclosed herein.

DETAILED DESCRIPTION

So that the manner in which the features and advantages of theembodiments of the systems and methods disclosed herein, as well asothers, which will become apparent, may be understood in more detail, amore particular description of embodiments of systems and methodsbriefly summarized above may be had by reference to the followingdetailed description of embodiments thereof, in which one or more arefurther illustrated in the appended drawings, which form a part of thisspecification. It is to be noted, however, that the drawings illustrateonly various embodiments of the embodiments of the systems and methodsdisclosed herein and are therefore not to be considered limiting of thescope of the systems and methods disclosed herein as it may includeother effective embodiments as well.

Recently enacted low carbon fuel standards provide incentives forconverting bio-feedstocks into refined products for use intransportation fuels, and technologies have been developed to producesuch refined products. These refined products are transported to atraditional refinery or terminal to be blended into fossil-based fuelsor otherwise upgraded. Such transportation and further upgrading mayinvolve the use of high carbon intensity methods (e.g., long-haul trucksusing fossil fuels, significant processing at the refinery, etc.). Therenewable diesel facility, biodiesel facility, ethanol plant, and otherrenewable transportation fuel units are typically located at or inseparate sites or locations apart from each other and traditionalrefineries/blend terminals. As such, products produced by each unit aretransported for blending or further processing. For example, the dieselproduct formed by some renewable diesel units contain ringed components,have low cetane (e.g., a cetane number between about −30 to 10), and isdark in color. Such a diesel product cannot be blended into CaliforniaAir Resources Board (CARE) diesel or ultra-low sulfur diesel (ULSD)diesel at appreciable volumes without further processing.

Applicants have recognized a need for systems and methods to providerenewable transportation fuels for internal combustion engines byconverting renewable feedstocks into two or more intermediatehydrocarbon blend stocks and blending at least two of the two or moreintermediate hydrocarbon blend stocks to produce the renewabletransportation fuel. The renewable feedstocks may be produced at arefinery or facility via co-located, on-site units. Additionally, therenewable feedstocks may be converted using renewable utilities, such asrenewable natural gas, renewable electricity (via wind, solar, orhydroelectric), etc. Moreover, the renewable natural gas may be used,e.g., in a steam reformer, to produce hydrogen for hydrotreating and/orhydrocracking operations. Thus, the co-location of at least a renewablediesel production unit, renewable naphtha/gasoline unit, and renewalnatural gas fed steam reformer enables the production of one or more ofa low carbon intensity, fully renewable liquefied petroleum gas (LPG),gasoline, jet, diesel, marine fuel, and other petrochemicals. Suchproducts are non-petroleum-based fuels, which are substantially devoidof fossil fuel-based components. Additionally, one or more other biomassor renewable feedstock units, such as an ethanol plant, may beco-located for the production and blending of ethanol into the finaltransportation fuel. Further, renewable utilities, such as renewablenatural gas, renewable electricity, etc., may be supplied to the processto further increase the sustainability of the produced transportationfuels. Since the renewable diesel production unit, the biodieselproduction unit, the renewable naphtha/gasoline, renewable natural gasfed steam reformer, and other transportation fuel units (e.g., ethanolplant), all supplied by renewable utilities, may be co-located, therefinery or facility may be operated to produce a one hundred percent ornear one hundred percent renewable biomass feedstock with a low carbonintensity, at least in relation to state of the art biofueltransportation and/or processing. Thus, the co-location of two or moreof the above-described renewable fuel units can create or define a fullyrenewable, or near-fully renewable, bio-refinery that introducesefficiencies and/or margin enhancements in excess of what may beachieved if the units are located at separate facilities or areco-located at a petroleum-based refinery. Additionally, the co-locationof one or more of the above-described renewable fuel units with aconventional crude oil refinery can create or define a near-fullyrenewable refinery that introduces efficiencies and/or marginenhancements in excess of what may be achieved if the units are locatedat separate facilities or at facilities apart from a conventionalpetroleum-based refinery.

The renewable diesel unit of a co-located refinery performshydrodeoxygenation (HDO) and isomerization steps on biomass-based orbiomass-derived feedstocks, including, but not limited to, vegetableoils, animal fats, used cooking oil, other lipids, or some combinationthereof. Such HDO and isomerization steps produce renewable diesel,naphtha or a low-grade naphtha, liquefied petroleum gas (LPG), and otherfuel gas products.

The renewable gasoline and/or other transportation fuel processes (e.g.,such as the Virent BioForming® processes) of the co-located refineryconvert sugars, such as glucose, and other aqueous carbohydrates into arenewable gasoline product (e.g., such as a Bioformate® product). Suchrenewable gasoline and/or other transportation fuel processes mayinclude the three process steps of hydrogenation (HYD), HDO, and acidcondensation (AC) that is then followed by a separations process tothereby separate out the renewable gasoline product and/or otherrenewable transportation fuel products (e.g., aviation, marine, jet,light ends, or other products). The renewable gasoline product and/orother renewable transportation fuel products can be processed usingexisting refining and petrochemical technologies into a range ofhydrocarbon products, biofuel products, and key renewable chemicals,including aromatics, diesel, LPG, fuel gas, bio p-xylene and biobenzene. Thus, the renewable gasoline and/or other transportation fuelprocesses transform renewable plant sugars into the same range ofhydrocarbon molecules (i.e., cut points) produced by refining petroleum.

Rather than having each unit in a separate location or facility,renewable diesel, biodiesel, renewable gasoline, and/or othertransportation fuel units (e.g., ethanol plant, etc.) are co-located,allowing for the co-mingling of intermediate streams, the blending ofproducts, and the shared use of hydrogen production, separations,utilities, and logistics infrastructure. Further, the renewable dieselunit, biodiesel unit, renewable gasoline and/or other transportationfuel units may be configured to be added as a kit or retrofit at anexisting refinery, e.g., enabling use of existing equipment. In suchexamples, some units or equipment may be adapted or re-configured foruse in such processes (e.g., configured to resist highly corrosiveproducts, different temperature ranges, and/or other characteristics, aswill be understood by a person skilled in the art).

As used herein, “carbon intensity” refers to the quantification of thedirect and indirect release of greenhouse gases attributable to consumerand/or industrial activity. The carbon intensity or emission intensitywas developed as a measure of the greenhouse gases emitted per unit ofactivity/production. With respect to transportation fuel, hydrogenproduction, other chemical production, and use of such products, thecarbon intensity may be defined as the lifecycle greenhouse gasesemitted per unit of energy. By assessing the lifecycle greenhouse gasemissions, all greenhouse gas emissions attributable to the fuel orhydrogen are accounted for during the entire lifecycle of the fuel orhydrogen from acquisition to processing to combustion. The carbonintensity for transportation fuels and hydrogen is often reported inunits of grams of carbon dioxide equivalent per mega joule of energy.Because some greenhouse gases, such as methane, are considered to have agreater climatic effect than carbon dioxide, greenhouse gas emissionsare reported in carbon dioxide equivalents.

FIG. 1 is a schematic diagram of a co-located refinery 172, according toone or more embodiments disclosed herein. The co-located refinery 172may include various components, equipment, or units to produce varioustransportation fuels, particularly renewable transportation fuels. Theco-located refinery 172 may utilize various, different feedstock toproduce the transportation fuels. The various processes utilized withinthe co-located refinery 172 may be implemented by different units, e.g.,a renewable diesel unit 120, a renewable gasoline or othertransportation fuel unit 170, a blending unit 154, a hydrogen productionunit 122, and/or other equipment or units, as will be described below.

As noted, the co-located refinery 172 may include a renewable dieselunit 120. The renewable diesel unit 120 may accept as feedstock fats andoils or other lipids 104. The fats and oils or other lipids 104 mayinclude vegetable oils, animal fats, used cooking oil, other lipids, orsome combination thereof. The fats and oils or other lipids 104 may beprovided to the co-located refinery 172 via various transportationmodes, such as rail, vehicle, marine vessel, and/or pipeline, and fromvarious sources. One source may include a wet or dry mill 154, which mayprovide oil 110 to the co-located refinery 172, as will be described infurther detail below.

The renewable diesel unit 120 may generate renewable diesel viahydrotreating or hydroprocessing of the fats and oils or other lipids104. The renewable diesel unit 120 may perform hydrodeoxygenation andisomerization of the fats and oils or other lipids 104 or otherbiomass-based feedstock. Other biomass-based feedstock may include cropresidues, wood, sawdust, and/or switchgrass. The renewable diesel unit120 may utilize hydrogen 124 in the processes described herein, thehydrogen 124 provided from a hydrogen production unit 122. The renewablediesel unit 120 may produce one or more output streams. The one or moreoutput streams may include low-grade naphtha 126, naphtha, renewablediesel 128, and/or sustainable aviation fuel 130. The renewable dieselunit 120 may connect to a separator 152. The one or more streams mayfeed into the separator 152. The naphtha or low-grade naphtha 126 mayinclude a benzene content of less than about 0.5 volume percent and aresearch octane number (RON) of less than about 60.

As noted, the co-located refinery 172 may include a renewable gasolineor other transportation fuel unit 170. The renewable gasoline or othertransportation fuel unit 170 may include various equipment orcomponents. For example, the renewable gasoline or other transportationfuel unit 170 may include a HYD reactor 112, a HDO reactor 114, and/oran AC unit 116. The HYD reactor 112 may reduce or saturate organiccompounds via a chemical reaction between hydrogen 124 (e.g., from thehydrogen production unit 122) and the feedstock (e.g., sugar 106 orsugar 108), with or without a catalyst. For example, the HYD reactor 112may produce a HYD sugar. The HDO reactor 114 may remove oxygen from theproduct of the HYD reactor 112 via a hydrogenolysis process. Hydrogen124 (e.g., from the hydrogen production unit 122) may be utilized insuch a process. Further, since sugar is an oxygen-rich precursor, such aprocess hydrogenolysis process may be utilized. The product of the HDOreactor 114 may be a HDO, HYD sugar. The product of the HDO reactor 114may be fed to an AC unit 116. The AC unit 116 may condense any acidgases within the product from the HDO reactor 114 and remove theresulting acidic condensate.

In an embodiment, the renewable gasoline or other transportation fuelunit 170 may include a separator 118. In another embodiment, theseparator 118 may not be considered a part of the renewable gasoline orother transportation fuel unit 170, but rather a separate component orseparate equipment. The separator 118 may separate different fluidsand/or gases from the product of the AC unit 116. The separator 118 mayseparate such a product into marine fuel 136, aviation fuel 138, and/orgasoline blend feedstock 140. The aviation fuel 138 may include orcontain synthesized kerosene (SK) and/or synthesized aromatic kerosene(SAK).

In an embodiment, sugar 106, 108 may be provided to the renewablegasoline or other transportation fuel unit 170. The sugar 106, 108 maybe provided from a number of sources. For example, sugar 106 may besourced from food waste, a refined sugar source (e.g., sugar cane,etc.), and/or sugar from other sources (e.g., corn, beets, grains,etc.).

In an embodiment, a wet or dry mill 154 may provide sugar 108, oil 110,and/or ethanol 132 to the co-located refinery 172. As illustrated, thewet or dry mill 154 may be located separately and at varying distances(e.g., nearby or at long distances). In another embodiment, the wet ordry mill 154 may be co-located at the co-located refinery 172. In anembodiment, a wet mill may include tanks to soak fermentable feedstock(e.g., corn) in a dilute aqueous sulfur dioxide solution. The softenedfermentable feedstock (e.g., corn) may be processed to remove the germ.The germ may be processed to produce oil (e.g., corn oil) for varioususes (e.g., renewable diesel production or animal feed). The remainingportion of the fermentable feedstock (e.g., after germ removal) isprocessed to produce feed and starch, as will be understood by thoseskilled in the art. The starch may further be processed into ethanol,e.g., in a co-located or off-site ethanol plant, as will be understoodby those skilled in the art.

In an embodiment, a dry mill may include a mill to grind a fermentablefeedstock to grist or meal of a particular granularity. A fermentablefeedstock may include organic matter including starches and/or sugar(e.g., corn, barley, wheat, sugar cane, beets, etc.) from a variety ofsources. The grist or meal may be transported for liquefaction and/orsaccharification, where the meal or grist is combined with a liquid(e.g., water) and heated to a specified temperature to form a mash ormixture. An amount of and type of enzymes (such as amylase) may beutilized (if any are to be used) to aid in the production ofsugars/saccharides from starches in the mash or mixture. Yeast may beadded to the mash or mixture once it has been cooled to a specifiedtemperature. The yeast may then enable fermentation of the sugars in themash or mixture. The fermented mash or mixture may then be distilledthereby forming ethanol. By-products of the process described for thedry mill and wet mill may include additional sugar and/or oil, inaddition to carbon dioxide (e.g., produced during fermentation). As suchand as noted, the wet or dry mill 154 may provide sugar 108, oil 110,and/or ethanol 132 to the co-located refinery 172.

As noted above, several processes or units at the co-located refinery172 may utilize hydrogen 124. Thus, the co-located refinery 172 mayinclude a hydrogen production unit 122. The hydrogen production unit 122may be a typical steam reformer and/or an electrolyzer. The input orfeedstock for a steam reformer may include a renewable natural gas (RNG)102, a typical fossil fuel based natural gas, or some combinationthereof. The steam reformer may be a methane steam reformer. The steamreforming process may produce hydrogen and carbon dioxide, among othergases, as will be understood by a person skilled in the art. In afurther embodiment, a portion of the renewable transportation fuel,particularly the renewable LPG 162, or any other intermediate productmay be utilized in a burner or furnace associated with the hydrogenproduction unit 122.

In another embodiment, rather than or in addition to a steam reformer,an electrolyzer may be utilized to generate hydrogen. The feedstock forthe electrolyzer may include varying types of water, such as gray water,treated gray water, salt water, fresh water, and/or other types ofwater, as will be understood by those skilled in the art. The energy orelectricity utilized to produce the hydrogen in an electrolyzer may beprovided via typical fossil-fuel based generators, wind turbines, solararrays, geothermal power plants/facilities, RNG-fired turbines, and/orRNG-produced steam letdown.

The co-located refinery 172 may include one or more separators 118, 150,152. The separator 118 associated with or included with the renewablegasoline or other transportation fuel unit 170 may output, as noted, amarine fuel 136, an aviation fuel 138, a gasoline blend stock 140,and/or light ends 148. The separator associated with or included withthe renewable diesel unit 120 may output marine fuel 136, aviation fuel142, low-grade naphtha 134, and/or light ends 146. The co-locatedrefinery 172 may include another separator 150. The separator 150 mayreceive the light ends 146 from separator 152 and light ends 148 fromseparator 118. The separator 150 may output a renewable LPG 162. In anembodiment, the aviation fuel 142 may include or contain hydroprocessedesters and fatty acids-synthetic paraffinic kerosene (HEFA-SPK).

The co-located refinery 172 may include a blend unit 154. The blend unit154 may include several blend sub-units 156, 158, 160. The blendsub-units 156, 158, 160 may be a tank or an in-line mixing system. Inembodiments, the type of blend sub-unit may depend on the type of blendto be output or the input into the blend sub-unit. In an example, toproduce a renewable gasoline 164, a low-grade naphtha 134, gasolineblend stock 140, and/or ethanol 132 may be blended in blend sub-unit 1156. To produce a sustainable aviation fuel 166, an aviation fuel 142and aviation fuel 138 may be blended in blend sub-unit 2 158. To producea sustainable marine fuel 168, a marine fuel 136 and marine fuel 136 maybe blended in blend sub-unit 3 160.

Several of the processes described above and herein may produce anamount of carbon dioxide and or other gases that may be deemed to beadverse to the environment. To further reduce carbon dioxide output orcarbon intensity of a resulting product (e.g., renewable LPG 162,renewable gasoline 164, sustainable aviation fuel 166, and/orsustainable marine fuel 168), several carbon reduction processes may beutilized. For example, each process may utilize a heat exchangernetwork. The heat exchanger network may include one or more heatexchangers that are arranged to provide heat to process streams (e.g.,process streams to be heated) by exchanging heat with other processstreams to be cooled. Thus, rather than burning fuel or usingelectricity to provide heat to a process, waste heat may be utilized. Inanother example, any of the various processes described herein mayutilize electricity generated from wind turbines, solar arrays,geothermal power plants/facilities, RNG-fired turbines, and/orRNG-produced steam letdown. In yet another example, any of the processesdescribed herein that produce carbon dioxide may utilize carbon captureand sequestration methods or processes to further reduce carbon outputor carbon intensity.

In an embodiment, the resulting product (e.g., renewable LPG 162,renewable gasoline 164, sustainable aviation fuel 166, and/orsustainable marine fuel 168) of the co-located refinery 172 may be a100% renewable product. In yet another embodiment, the co-locatedrefinery 172 may include other refining equipment or units to producefossil fuel based products. The fossil fuel based products may beblended with the products from the renewable diesel unit 120 and/or therenewable gasoline or other transportation fuel unit 170, as well asethanol 132, thus forming a transportation fuel that includes at least aportion or a substantial portion of renewable transportation fuel.

FIGS. 2A-2F are flow diagrams for providing or producing renewabletransportation fuels according to an embodiment. The method 200 isdetailed with reference to the co-located refinery 172 of FIG. 1 . Theactions of method 200 may also be completed or implemented within thecontroller 302. Specifically, method 200 may be included in one or moreprograms, protocols, or instructions loaded into the memory 306 of thecontroller 200 and executed on the processor 304 or one or moreprocessors of the controller 200. The order in which the operations aredescribed is not intended to be construed as a limitation, and anynumber of the described blocks may be combined in any order and/or inparallel to implement the methods.

At block 202, the co-located refinery 172 or a controller (e.g.,controller 302) at the co-located refinery 172 may receive a type offuel to blend and/or specification for the type of fuel. A specificationfor a type of fuel may be based on California Air Resources Board (CARE)diesel standards or ultra-low sulfur diesel (ULSD) diesel standards,among other fuel standards as will be understood by the person skilledin the art. Parameters included in the specification may include typesof fuel to blend, amount or percentage of each fuel in the final blend,amount of sulfur allowable in the blend, a carbon intensity of theblend, cetane number, octane number, RON, motor octane number, and/orother fuel parameters. The specification may additionally include thefinal type of fuel, e.g., such as marine fuel, aviation fuel, diesel,gasoline, LPG, and/or other fuels as will be understood by a personskilled in the art.

At block 204, the sugar 106 for the process may be selected. The sugar106 may include one or more different types of sugar 106 in one or moredifferent forms (e.g., solid or liquid). The sugar 106 may betransported to the co-located refinery 172 upon selection. In otherembodiments, the one or more types of sugar 106 may be at or proximateto the co-located refinery 172.

At block 206, the sugar 106 may be introduced to one or more reactors(e.g., at a renewable gasoline or other transportation fuel unit 170).The one or more reactors may include a HYD 112 reactor and an HDOreactor 114. An AC unit 116 may be included in the renewable gasoline orother transportation fuel unit 170, and the product of the a HYD 112reactor and an HDO reactor 114 may pass through the AC unit 116.

At block 208, sugar 106 may be converted to an intermediate blend stock.Such a conversion may occur via operation of the one or more reactors.Such an operation may produce an intermediate blend stock. The resultingintermediate blend stock, at block 210, may be passed through a firstseparation unit (e.g., separator 118). The first separation unit mayproduce one or more different feedstock (e.g., a gasoline blend stock,aviation blend stock, marine blend stock, and/or light ends). Thegasoline blend stock may be output from the separation unit to a firstblend unit (e.g., blend unit 1 156).

At block 214, a lipid (e.g., fats and oils or lipids 104) may beselected, for example, by the controller 302 or the co-located refinery172. The lipid may be selected based on a type of fuel to be produced.The lipid may include one or more of vegetable oils, animal fats, usedcooking oil, other lipids, or some combination thereof.

At block 216, once the lipid is selected, the lipid may be introduced tothe renewable diesel unit 120. At block 218, once the lipid isintroduced to the renewable diesel unit 120, the renewable diesel unit120 may be operated to produce one or more of diesel, naphtha orlow-grade naphtha, sustainable aviation fuel blend stock, and/orsustainable marine fuel blend stock.

At block 220, the products of the renewable diesel unit 120 may bepassed to a second separation unit (e.g., separator 152). The secondseparation unit may output various products, such as naphtha, aviationfuel, marine fuel, and/or light ends. At block 222, the naphtha may beoutput from the second separation unit and transported to the firstblend unit (e.g., blend unit 1 156).

At block 224, the naphtha, gasoline blend stock, and/or an ethanol blendstock may be blended in the first blend unit according to thespecification. In other words, the specified amounts of each product maybe output to the first blend unit or each product may be blended tothereby form a final blend or product meeting the parameters of thespecification.

At block 226, the resulting product may be sampled or measured todetermine a composition of the blend. Such sampling or measurement mayoccur to determine whether the blend meets the specification (e.g.,octane number, sulfur content, etc.). If the resulting blend does notmeet the specification, additional products may be added to the blend,based on the type and value of the parameter that does not meet thespecification. At block 228, if the blend meets the specification orparameters of the specification, a renewable gasoline may be output foruse in an internal combustion engine.

At block 230, a carbohydrate feedstock or a fermentable feedstock may beintroduced to an ethanol plant (e.g., wet or dry mill 154). In anembodiment, the ethanol plant may be included at the co-located refinery172 or separate from the co-located refinery 172.

At block 232, the carbohydrate feedstock or a fermentable feedstock maybe fermented. Other steps may be included in the ethanol production. Atblock 234, the fermented carbohydrate may be distilled to produceethanol or a blend stock. At block 236, the blend stock may be sent to athird separation unit and, at block 238, ethanol may be output form thethird separation unit. In another embodiment, after distillation, theethanol may be sent directly to a first blend unit for blending, ratherthan to a separator.

At block 240, RNG 102 or another natural gas may be introduced to areformer (e.g., hydrogen production unit 122). The reformer, at block242, may be operated to produce hydrogen 124 from the RNG 102. At block244, the hydrogen 124 may be sent to the renewable diesel unit 122. Inan embodiment, other units at the co-located refinery may utilize thehydrogen (e.g., the HYD 112 and/or the HDO 114, among other units).

At block 246, the first separator may output an aviation fuel blendstock. The first aviation fuel blend stock may be output to or receivedby a second blend unit, at block 248. At block 250, the second separatormay output a second aviation fuel blend stock. The second aviation fuelblend stock may be output to or received by the second blend unit, atblock 252. Once the appropriate amount of each blend stock is received,the second blend unit may be operated to blend the first and secondaviation fuel blend stock. The resulting blend may be sampled oranalyzed to determine whether the blend meets the specification orspecification parameters, at block 256. If the parameters are not met,the blend may be adjusted, by adding more of either of the blend stocks.If the blend does meet the specification, the blend may be output as asustainable aviation fuel, at block 258.

At block 260, the first separator may output a marine fuel blend stock.The first marine fuel blend stock may be output to or received by athird blend unit, at block 260. At block 264, the second separator mayoutput a renewable diesel. The renewable diesel, which may be consideredULSD, may be output to or received by the third blend unit, at block266. Once the appropriate amount of each blend stock is received, thethird blend unit may be operated to blend the first marine fuel blendstock and the renewable diesel. The resulting blend may be sampled oranalyzed to determine whether the blend meets the specification, atblock 270. If the parameters are not met, the blend may be adjusted, byadding more of either of the blend stocks. If the blend does meet thespecification, the blend may be output as a sustainable aviation fuel,at block 272.

At block 274, the first separator may output first light ends. The firstlight ends may be output to or received by a third separator, at block276. At block 278, the second separator may output second light ends.The second light ends may be output to or received by the third blendunit separator, at block 280. Once the appropriate amount of each lightend is received, the third separator, at block 282, may be operated toproduce a renewable LPG. The resulting renewable LPG may be sampled oranalyzed to determine whether the renewable LPG meets the specification,at block 284. If the parameters are not met, the renewable LPG may beadjusted, by adding more of either of the light ends. If the renewableLPG does meet the specification, the renewable LPG may be output, atblock 286.

FIGS. 3A through 3B are simplified diagrams illustrating a controlsystem 300 for managing the production of renewable transportationfuels, according to one or more embodiments disclosed herein. In anexample, the control system 300 may include a controller 302 or one ormore controllers. Further, the controller 302 may be in signalcommunication with various other controllers throughout or external tothe co-located refinery. The controller 302 may be considered asupervisory controller. In another example, a supervisory controller mayinclude the functionality of controller 302.

Each controller described above and herein may include amachine-readable storage medium (e.g., memory 306) and one or moreprocessors (e.g., processor 304). As used herein, a “machine-readablestorage medium” may be any electronic, magnetic, optical, or otherphysical storage apparatus to contain or store information such asexecutable instructions, data, and the like. For example, anymachine-readable storage medium described herein may be any of randomaccess memory (RAM), volatile memory, non-volatile memory, flash memory,a storage drive (e.g., hard drive), a solid state drive, any type ofstorage disc, and the like, or a combination thereof. The memory 306 maystore or include instructions executable by the processor 304. As usedherein, a “processor” may include, for example one processor or multipleprocessors included in a single device or distributed across multiplecomputing devices. The processor 304 may be at least one of a centralprocessing unit (CPU), a semiconductor-based microprocessor, a graphicsprocessing unit (GPU), a field-programmable gate array (FPGA) toretrieve and execute instructions, a real time processor (RTP), otherelectronic circuitry suitable for the retrieval and executioninstructions stored on a machine-readable storage medium, or acombination thereof.

As used herein, “signal communication” refers to electric communicationsuch as hard wiring two components together or wireless communication,as understood by those skilled in the art. For example, wirelesscommunication may be Wi-Fi®, Bluetooth®, ZigBee, or forms of near fieldcommunications. In addition, signal communication may include one ormore intermediate controllers or relays disposed between elements thatare in signal communication with one another. In the drawings andspecification, several embodiments of renewable transportation fuelcompositions and methods of making such renewable transportation fuelcompositions are disclosed. The controller 302 may include instructions308 to produce renewable and sustainable fuel and other products.Instructions 308, as illustrated in FIG. 3B may include severalsub-routines, sub-instructions, or instructions to produce a number ofsustainable and/or renewable transportation fuels.

The controller may include instructions 328, to cause a co-locatedrefinery to produce a renewable gasoline. In such an example, thecontroller 302 may determine what type of gasoline to produce and whatto include in such a product based on a specification received, forexample, from a user interface 326. In another example, thespecification may be pre-loaded into the instructions or memory 306,prior to initiation of such a process. Once such a process is initiatedthe controller 302 may send signals to the renewable diesel unit 310,the reactor 312, separator 1 314, separator 2 316, a reformer 320, anethanol plant/unit 322, and/or a blender unit 324. The signals mayinclude operating parameters for each unit, such as temperatures, lengthof operating time, amount of incoming feedstock, amount of product to beproduced, as well as other parameters. Other parameters may includecetane number, RON number, MON number, sulfur content, among otherparameters relevant to the renewable gasoline as will be understood by aperson skilled in the art. The controller 302 may monitor the processuntil the process is complete and ensure that the final renewablegasoline meets the specification and, if not, then adjusting the blendof the renewable gasoline.

The controller 302 may include instructions 334, to cause a co-locatedrefinery to produce a renewable diesel. In such an example, thecontroller 302 may determine what type of diesel to produce and what toinclude in such a product based on a specification received, forexample, from the user interface 326. In another example, thespecification may be pre-loaded into the instructions, prior toinitiation of such a process. Once such a process is initiated thecontroller 302 may send signals to the renewable diesel unit 310, thereactor 312, separator 1 314, separator 2 316, a reformer 320, anethanol plant/unit 322, and/or a blender unit 324. The signals mayinclude operating parameters for each unit, such as temperatures, lengthof operating time, amount of incoming feedstock, amount of product to beproduced, as well as other parameters. Other parameters may includecetane number, RON number, MON number, sulfur content, among otherparameters relevant to renewable diesel (e.g., such as paraffiniccontent) as will be understood by a person skilled in the art. Thecontroller 302 may monitor the process until the process is complete andensure that the final renewable diesel meets the specification and, ifnot, then adjusting the blend of the renewable diesel.

The controller may include instructions 330, to cause a co-locatedrefinery to produce a sustainable aviation fuel. In such an example, thecontroller 302 may determine what type of aviation fuel to produce andwhat to include in such a product based on a specification received, forexample, from the user interface 326. In another example, thespecification may be pre-loaded into the instructions, prior toinitiation of such a process. Once such a process is initiated thecontroller 302 may send signals to the renewable diesel unit 310, thereactor 312, separator 1 314, separator 2 316, a reformer 320, anethanol plant/unit 322, and/or a blender unit 324. The signals mayinclude operating parameters for each unit, such as temperatures, lengthof operating time, amount of incoming feedstock, amount of product to beproduced, as well as other parameters. Other parameters may includecetane number, RON number, MON number, sulfur content, among otherparameters relevant to sustainable aviation fuel as will be understoodby a person skilled in the art. The controller 302 may monitor theprocess until the process is complete and ensure that the finalsustainable aviation fuel meets the specification and, if not, thenadjusting the blend of the sustainable aviation fuel.

The controller may include instructions 336, to cause a co-locatedrefinery to produce a sustainable marine fuel. In such an example, thecontroller 302 may determine what type of marine fuel to produce andwhat to include in such a product based on a specification received, forexample, from the user interface 326. In another example, thespecification may be pre-loaded into the instructions, prior toinitiation of such a process. Once such a process is initiated thecontroller 302 may send signals to the renewable diesel unit 310, thereactor 312, separator 1 314, separator 2 316, a reformer 320, anethanol plant/unit 322, and/or a blender unit 324. The signals mayinclude operating parameters for each unit, such as temperatures, lengthof operating time, amount of incoming feedstock, amount of product to beproduced, as well as other parameters. Other parameters may includecetane number, RON number, MON number, sulfur content, among otherparameters relevant to sustainable marine fuel as will be understood bya person skilled in the art. The controller 302 may monitor the processuntil the process is complete and ensure that the final sustainablemarine fuel meets the specification and, if not, then adjusting theblend of the sustainable marine fuel.

The controller may include instructions 332, to cause a co-locatedrefinery to produce a renewable LPG. In such an example, the controller302 may determine what type of LPG to produce and what to include insuch a product based on a specification received, for example, from theuser interface 326. In another example, the specification may bepre-loaded into the instructions, prior to initiation of such a process.Once such a process is initiated the controller 302 may send signals tothe renewable diesel unit 310, the reactor 312, separator 1 314,separator 2 316, separator 3 318, a reformer 320, an ethanol plant/unit322, and/or a blender unit 324. The signals may include operatingparameters for each unit, such as temperatures, length of operatingtime, amount of incoming feedstock, amount of product to be produced, aswell as other parameters. Other parameters may include cetane number,RON number, MON number, sulfur content, among other parameters relevantto renewable LPG as will be understood by a person skilled in the art.The controller 302 may monitor the process until the process is completeand ensure that the final renewable LPG meets the specification and, ifnot, then adjusting the blend of the renewable LPG.

In another embodiment, various sensors and meters may be disposedthrough the system 300 or the co-located refinery 172. Such sensors andmeters may be in signal communication with the controller 302 and mayprovide data or feedback to the controller 302 to determine variousproperties of each unit and/or product at various stages in the process.The sensors and meters may measure flow, density, chemical properties,temperature, pressure, and/or other properties, as will be understood bya person skilled in the art.

This is a continuation of U.S. Non-Provisional application Ser. No.18/112,565, filed Feb. 22, 2023, titled “SYSTEMS AND METHODS OFCONVERTING RENEWABLE FEEDSTOCKS INTO INTERMEDIATE HYDROCARBON BLENDSTOCKS AND TRANSPORTATION FUELS,” which is a continuation of U.S.Non-Provisional application Ser. No. 17/848,443, filed Jun. 24, 2022,titled “SYSTEMS AND METHODS OF CONVERTING RENEWABLE FEEDSTOCKS INTOINTERMEDIATE HYDROCARBON BLEND STOCKS AND TRANSPORTATION FUELS,” nowU.S. Pat. No. 11,613,715, issued Mar. 28, 2023, which claims priority toand the benefit of U.S. Provisional Application No. 63/262,426, filedOct. 12, 2021, titled “SYSTEMS AND METHODS OF CONVERTING RENEWABLEFEEDSTOCKS INTO INTERMEDIATE HYDROCARBON BLEND STOCKS AND TRANSPORTATIONFUELS,” the disclosures of which are incorporated herein.

Although specific terms are employed herein, the terms are used in adescriptive sense only and not for purposes of limitation. Embodimentsof systems and methods have been described in considerable detail withspecific reference to the illustrated embodiments. However, it will beapparent that various modifications and changes can be made within thespirit and scope of the embodiments of systems and methods as describedin the foregoing specification, and such modifications and changes areto be considered equivalents and part of this disclosure.

What is claimed is:
 1. A process to provide renewable transportationfuels, the process comprising: converting sugar in one or more reactorsinto an intermediate renewable hydrocarbon blend stock within the one ormore reactors; separating at least an intermediate renewable gasolineblend stock from the intermediate renewable hydrocarbon blend stock;providing one or more lipids to a renewable diesel unit the one or morelipids comprises one or more of vegetable oils, animal fats, or usedcooking oil; operating the renewable diesel unit to yield a renewablediesel product from the one or more lipids; separating at leastrenewable diesel and low-grade naphtha of the renewable diesel product,the low-grade naphtha having a benzene content less than about 0.5volume percent and a research octane number of less than about 60;blending the low-grade naphtha and the intermediate renewable gasolineblend stock so that a resulting blend defines a finished renewablegasoline.
 2. The process of claim 1, wherein the renewable dieselproduct includes at least a low-grade naphtha and a renewable diesel,and the process further comprising: selecting, via one or morecontrollers, the sugar from a sugar source, providing the sugar from thesugar source to the one or more reactors, and prior to providing the oneor more lipids into the renewable diesel unit, selecting, via the one ormore controllers, the one or more lipids from a lipid source.
 3. Theprocess of claim 2, wherein the sugar source comprises sugar processedin a wet or dry mill.
 4. The process of claim 1, further comprising:introducing a carbohydrate feedstock to an ethanol plant; operating anethanol fermentation and distillation process in the ethanol plant toconvert the carbohydrate feedstock into at least an ethanol product;separating an ethanol blend stock from the ethanol product in an ethanolseparator; and blending the ethanol blend stock with the low-gradenaphtha and the intermediate renewable gasoline blend stock so that theresulting blend defines the finished renewable gasoline.
 5. The processof claim 1, further comprising: introducing renewable natural gas as areformer unit feedstock to a reformer unit; producing at least hydrogengas through conversion of the renewable natural gas in the reformerunit; and introducing at least a portion of the hydrogen gas into atleast one of the one or more reactors to hydrogenate the sugar ordehydrodeoxygenate the hydrogenated sugar.
 6. The process of claim 1,further comprising: introducing renewable natural gas as a reformer unitfeedstock to a reformer unit; producing at least hydrogen gas byconversion of the renewable natural gas in the reformer unit; andintroducing at least a portion of the hydrogen gas into the renewablediesel unit to produce the renewable diesel and the low-grade naphtha.7. The process of claim 1, wherein the intermediate renewablehydrocarbon blend stock further includes a first sustainable aviationfuel blend stock that contains synthesized kerosene (SK) or synthesizedaromatic kerosene (SAK) and the renewable diesel product furtherincludes a second sustainable aviation fuel blend stock that containshydroprocessed esters and fatty acids-synthetic paraffinic kerosene(HEFA-SPK).
 8. The process of claim 7, further comprising: separatingthe first sustainable aviation fuel blend stock from the intermediaterenewable hydrocarbon blend stock in the first separation unit;separating the second sustainable aviation fuel blend stock from therenewable diesel unit in the second separation unit; and blending thefirst sustainable aviation fuel blend stock and the second sustainableaviation fuel blend stock into a renewable sustainable aviation fuel. 9.The process of claim 1, wherein the intermediate renewable hydrocarbonblend stock further includes a precursor marine fuel blend stock. 10.The process of claim 9, further comprising: separating the precursormarine fuel blend stock from the intermediate renewable hydrocarbonblend stock in the first separation unit; and blending an amount of therenewable diesel with the precursor marine fuel blend stock to define arenewable marine fuel.
 11. The process of claim 1, wherein the finishedrenewable gasoline is outputted as a non-petroleum-based fuel.
 12. Theprocess of claim 1, wherein the finished renewable gasoline issubstantially devoid of any fossil fuel-derived components, and whereinthe converting of the sugar comprises a conversion through (a)hydrogenation of the sugar, (b) hydrodeoxygenation of the hydrogenatedsugar, and (c) acid condensation of the hydrodeoxygenated, hydrogenatedsugar.
 13. A process to provide renewable transportation fuels, theprocess comprising: converting sugar in one or more reactors into anintermediate renewable hydrocarbon blend stock within the one or morereactors; passing the intermediate renewable hydrocarbon blend stockthrough a first separation unit, thereby to separate out at least afirst sustainable aviation fuel blend stock that contains one or more ofsynthesized kerosene (SK) or synthesized aromatic kerosene (SAK);operating a renewable diesel unit, thereby to yield a renewable dieselproduct from one or more lipids in the renewable diesel unit; passingthe renewable diesel product through a second separation unit toseparate out at least a second sustainable aviation fuel blend stockthat has at least one of hydroprocessed esters and fatty acids-syntheticparaffinic kerosene (HEFA-SPK); blending at least the first sustainableaviation fuel blend stock and the second sustainable aviation fuel blendstock so that a resulting blend defines a sustainable aviation fuel. 14.The process of claim 13, further comprising: selecting the sugar from asugar source; providing the sugar to one or more reactors, selecting theone or more lipids from a lipid source; and providing the one or morelipids to the renewable diesel unit, and wherein the converting of thesugar comprises a conversion through (a) hydrogenation of the sugar, (b)hydrodeoxygenation of the hydrogenated sugar, and (c) acid condensationof the hydrodeoxygenated, hydrogenated sugar.
 15. A process to providerenewable transportation fuels, the process comprising: converting sugarinto an intermediate renewable hydrocarbon blend stock; passing theintermediate renewable hydrocarbon blend stock through a firstseparation unit to separate out at least a sustainable marine fuel blendstock; operating a renewable diesel unit having one or more lipidstherein, thereby to yield a renewable diesel product from the one ormore lipids; passing the renewable diesel product through a secondseparation unit to separate out at least a renewable diesel; andblending at least the sustainable marine fuel blend stock and therenewable diesel so that the resulting blend defines a sustainablemarine fuel.
 16. The process of claim 15, further comprising introducingthe sugar to one or more reactors, selecting the sugar from a sugarsource, and selecting the one or more lipids from a lipid source, andwherein the converting of the sugar comprises a conversion through (a)hydrogenation of the sugar, (b) hydrodeoxygenation of the hydrogenatedsugar, and (c) acid condensation of the hydrodeoxygenated, hydrogenatedsugar.
 17. A system to provide renewable transportation fuels, thesystem comprising: one or more reactors, having an inlet to receivesugar and an outlet, configured to hydrogenate the sugar,hydrodeoxygenate the hydrogenated sugar, and facilitate acidcondensation of the hydrodeoxygenated, hydrogenated sugar when the sugaris positioned in the one or more reactors, thereby to produce anintermediate renewable hydrocarbon blend stock; a first separation unitconnected to and in fluid communication with the outlet of the one ormore reactors, the first separation unit operable to separate theintermediate renewable hydrocarbon blend stock into at least anintermediate renewable gasoline blend stock; a renewable diesel unithaving an inlet to receive one or more lipids and an outlet, therenewable diesel unit configured to yield a renewable diesel productfrom the one or more lipids when positioned in the renewable dieselunit; a second separation unit connected to and in fluid communicationwith the outlet of the renewable diesel unit, the second separation unitoperable to separate the renewable diesel product into at least arenewable diesel blend stock and a low-grade naphtha, the low-gradenaphtha having a benzene content less than about 0.5 volume percent anda research octane number of less than about 60; and a blending unit toblend together at least the intermediate renewable gasoline blend stockfrom the first separation unit and the low-grade naphtha from the secondseparation unit.
 18. The system of claim 17, further comprising: asource of carbohydrate feedstock; an ethanol production plant with aninlet that receives the carbohydrate feedstock from the source ofcarbohydrate feedstock, the ethanol production plant operable to convertthe carbohydrate feedstock into an ethanol blend stock that leaves theethanol production plant through an outlet thereof; and a flow linebetween the outlet of the ethanol production plant and the blending unitto pass the ethanol blend stock to the blending unit for blending withthe intermediate renewable gasoline blend stock and the low-gradenaphtha.
 19. The system of claim 17, further comprising: a source ofrenewable natural gas; a hydrogen production unit with an inlet thatreceives the renewable natural gas from the source of renewable naturalgas, the hydrogen production unit operable to convert the renewablenatural gas into a hydrogen gas that leaves the hydrogen production unitthrough one or more outlets thereof; a first flow line between the oneor more outlets of the hydrogen production unit and the at least onereactor to provide a first portion of the hydrogen gas thereto; and asecond flow line between the one or more outlets of the hydrogenproduction unit and the renewable diesel unit to provide a secondportion of the hydrogen gas thereto.